Setting tool apparatus



Jul 14, 1970 Filed Oct. 28, 1968 J. w. KISLING 3,520,360

SETTING TOOL APPARATUS 2 Sheets$heet .3-

United States Patent 3,520,360 SETTING TOOL APPARATUS James W. Kisling III, Houston, Tex., assignor to Schlumberger Technology Corporation, New York, N.Y., a corporation of Texas Filed Oct. 28, 1968, Ser. No. 771,179 Int. Cl. E21b 23/06 US. Cl. 166-123 8 Claims ABSTRACT OF THE DISCLOSURE A setting tool apparatus for use in setting well tools in well bores includes inner and outer members movable in opposite directions relative to one another for applying oppositely directed forces to the well tool. The outer member has an upwardly facing pressure surface and the inner member has a downwardly facing pressure surface forming movable walls of a fluid-filled hydraulic chamber. An operator member connected to the lower end of a pipe string can be moved upwardly by the pipe string into engagement with a piston ring, and upward strain on the pipe string and piston ring will generate a fluid pressure in the chamber which acts on the pressure surfaces of the members to cause relative movement in opposite directions. The area of the pressure surface on said inner member is larger than the area of said piston ring, whereby the upward force on said inner member tending to cause relative movement is a multiple of the upward strain on the pipe string.

This invention relates generally to well tools used in well bores, and more specifically to mechanical setting tools operable by manipulation of a pipe string for setting well tools such as packers, plugs and retainers in a well conduit.

The aforementioned well tools which can be lowered into a well conduit on a pipe string and then set by manipulation of the pipe string to pack oif the well bore, generally include a mandrel which carries upper and lower normally retracted slips and a packing element arranged to be expanded into contact with the well conduit wall. Expansion of the slips and packing element can be effected by the application of oppositely directed forces, usually a downward force on the upper slip together with an upward force on the mandrel. In response to such forces, the slips are shifted outwardly by cooperatively arranged expander cones, and the packing element is compressed and expanded into sealing engagement with the well conduit.

The application of such oppositely directed forces may be accomplished through use of a mechanical setting tool which is coupled between the well tool and the pipe string. A typical mechanical setting tool includes an inner member having its lower end connected to the packer mandrel by a shear stud or the like, and its upper end connected to the pipe string, and an outer member having friction blocks engaging the conduit and which is coupled in force transmitting relationship with the upper slips. By appropriate manipulation of the pipe string, the upper slip can be shifted into gripping contact with the conduit, after which an upward strain on the pipe string at the earths surface will effect expansion of the lower slip and the packing element.

In the past, mechanical setting tools have not been usable at very great depths because the upward strain which can be applied at the surface to operate the setting tool and set the packer is limited by the tensile strength of the pipe string. The deeper the setting depth, the greater the weight of pipe in the well, so that a lesser amount of strain can be applied at the surface to operate 3,520,360 Patented July 14, 1970 ice the setting tool without exceeding the recommended tensile strength of the pipe. However, in recent times, wells are being driller deeper and deeper below the earths surface requiring setting of packers at corresponding greater depths. Thus, the foregoing limitations in using conventioal mechanical setting tools are becoming more critical.

A general object of the present invention is to provide a new and improved setting tool for packers or the like, which is constructed and arranged for setting a well tool on a pipe string, and which incorporates a hydraulic force multiplying means enabling a reduction in the strain applied to the pipe string at the surface to produce an adequate setting force to the tools. Although the present invention may be used at any depth in a well bore, it has particular utility in setting tools at great depths below the surface.

"With this and other subjects in view, apparatus in accordance with the concepts of the present invention includes inner and outer telescopically arranged members movable in opposite longitudinal directions and coupled in force transmitting relationship to relatively movable parts of a well tool. Piston means on said members have opposed transverse pressure surfaces and provide a fluidfllled chamber. A pressure generating means is disposed in said inner member and connected to the pipe string and is movable upwardly by the pipe string for generating a fluid pressure in said chamber. The fluid pressure in said chamber acts on said opposed pressure surfaces to force said members in opposite longitudinal directions. The transverse pressure area of one of said piston means is greater than the transverse pressure area of said generating means, so that the force on one of said members due to fluid pressure in said chamber is a multiple of the force applied to said generating means by the pipe string. Thus, it will be appreciated that a lesser strain can be applied to the pipe string at the surface to obtain the required setting force for the packer, which enables setting at greater depths for the packer without exceeding the strength of the pipe string.

The present invention has other concepts and advantages which will become more apparent in connection with the following detailed description of an exemplary embodiment. Such embodiment is shown in the accompanying drawing in which:

FIG. 1 is a somewhat schematic view of a well packer and setting tool disposed in a well bore on a pipe string;

FIGS. 2A and 2B are sectional views with portions in side elevation, of the setting tool of the present invention with parts in their relative positions before setting of the well packer, FIG. 28 forming a lower continuation of FIG. 2A; and

FIGS. 3A and 3B are views similar to FIGS. 2A and 2B, but with parts in their relative positions after the well tool has been set in the well bore.

Referring initially to FIG. 1, a schematic representation of a well tool 10 such as a packer, plug or retainer, is coupled to a mechanical setting tool 11, which incorporates the principles of the present invention, and is suspended in a well casing 12 on a running-in string 13 of tubing or drill pipe. The well tool 10 includes a central mandrel 14 carrying normally retracted upper and lower slips 15 and 16 which can be shifted outwardly by upper and lower companion expander cones 17 and 18. A packing element 19 is disposed between the expander cones and is arranged to be expanded outwardly when subjected to longitudinal compression force. A conventional body lock ring 20 is cooperable within a setting head 21 to grip the mandrel 14 and trap the slips 15 and 18 and the packing element 19 in expanded positions.

Turning now to FIGS. 2A and 2B for details of the setting tool apparatus 11, an outer tubular member 25 is telescopically disposed upon an inner tubular member 26, the members being arranged for longitudinal movement in opposite directions relative to one another. The lower end portion of the outer member can be constituted by a threadedly attached sleeve 27 which extends downwardly into abutting relationship with the setting head 21 and is accordingly coupled to force the setting head downwardly relative to the mandrel 14. The lower end portion of the inner member 26 can be constituted by a threadedly attached sleeve 28 which extends over the upper end portion of the mandrel 14 and which is releasably coupled thereto by, a conventional shear ring 29. Thus, the inner member 26 is coupled to the mandrel 14 for transmitted upward force thereto until the shear value of the ring 29 is reached, at which point the ring can shear and release the inner member 26 from the well tool 10. Although the use of an annular shear ring as shown enables a full-opening bore through the setting tool, it will be equally appreciated that a conventional tension stud could be used to connect the inner member 26 to the mandrel 14.

The upper end of the outer member 25 is connected to a cage member 30 having a plurality of radially directed recesses '31, each of which receives a drag block 32 which is urged outwardly by a coil spring 33 or the like. The drag blocks 32 can slide along the inner wall of the well casing and yieldably resist both longitudinal and rotatational movement. A coupling sleeve 34 extends upwardly from the cage member 30 and has an internal splined recess 35 and an upwardly opening J-slot 36 for purposes which will be described hereafter.

The outer member 25 has a shouldered piston section 40 extending inwardly toward the inner member 26 and sealed against the outer periphery of the inner member by a seal ring 41. The shoulder configuration of the piston section 40 provides an upwardly facing transverse pressure surface 42. The upper end of the inner member 26 is formed by an annular piston head 43 which'is sealed against the inner periphery of the outer member 25 by a seal ring 44. The piston head 43 has downwardly facing pressure surfaces 45 and 45' which are communicated via a radial port 46, the pressure surfaces on the piston head 43 and the outer member 25 being disposed so as to face one another. The annular space between the piston section 40 and the head 43 provides a chamber 47 which is filled with a suitable hydraulic fluid.

Telescopically disposed within the inner member 26 is a tubular operating member 50 having its upper end connected to the lower end of the running-in string 13 by a collar or the like. An annular shoulder 51 is formed near the lower end of the member 26, and an annular, floating piston ring 52 is disposed between the operator member 50 and the inner member 26. Suitable seal rings 53 and 54 prevent fluid leakage past the ring 52.

During lowering into a well bore, relative longitudinal movement between the various members 50, 26 and 25 is prevented by engagement of a lug 56 on the operator member 50 within the closed segment 57 (FIG. 1) of the J-slot 36. Moreover, an inwardly extending shoulder 58 on the outer member 26 engages below the shoulder 51 on the operator member 50. Thus, the parts are held in the positions shown in FIG. 2A and 2B until, by appropriate manipulation of the running-in string 13, the lug 56 is indexed into the open-ended segment 59 of the J-slot to enable upward movement of the operator member 50 relative to the inner member 26.

Further provision is made for controlling the extent of longitudinal relative movement between the various members, including a stop nut 60 threadedly engaging the operator member 50 and co-rotatively secured to the inner member 26 by splines 61. After the lug 56 is released from the J-slot 36 as previously described, the operator member 50 can be reciprocated upwardly until the nut 60 engages the top of the recess 35, at which point the operator member must be rotated by the running-in string 13 to the right to unthread the nut 60 from threads 62 to enable further upward movement of the operator member 50. As shown in FIG. 2B, the piston ring 52 isinitially spaced upwardly from the shoulder 51 a distance to permit the operator member 50 to be moved upwardly to the extent necessary to unthread the nut 60 before the shoulder 51 picks up the ring 52.

If it is desired to maintain the members telescoped after the setting tool has been operated, the inner member 26 may be provided with an internal annular recess 64 which receives an annular, split clutch ring 65 having upwardly facing teeth 66 on its inner periphery. A longitudinally disposed spline 67 on the inner member 26 engages within the split in the clutch ring 65 to prevent relative rotation. Downwardly facing teeth 68 are formed onthe outer periphery of a central section of the operator member 50 below the clutch ring 65, so that when the operator member is moved upwardly relative to the inner member 26, the teeth 68 will ratchet through the clutch ring 65, and the clutch ring will trap the operator member 50 in an upper position relative to the inner member.

In operation, the parts can be assembled as shown in FIGS. 2A and 2B and coupled to the well tool 10 to be lowered and set in the well bore. During lowering, the lug 56 on the operator member 50 is positioned with in the closed segment 57 of the J-slot 36, and the drag blocks 32 engage the casing wall and are pushed downwardly in the casing by the weight of the running-in string 13. At setting depth, the assembly is halted, the running-in string 13 is torqued a part turn to the left and then lifted to disengage the lug 56 from the J- slot 36, and then the running-in string is rotated several turns to the right to unthread the stop nut 60 from the operator member 50, the drag blocks 32 preventing rotation of the cage member 30 and the stop nut. After the stop nut 60 is disengaged, the operator member 50 is free to be moved upwardly by the running-in string relative to the inner and outer members 26 and 25 to cause setting of the well tool 10.

Elevation of the running-in string 13 at the top of the well bore causes the shoulder 51 to pick up the piston ring 52. Due to the resistance afforded by the drag blocks 32 to upward movement of the outer member 25, upward force on the piston ring 52 generates a fluid pressure in the chamber 47 which acts upwardly on the lower surfaces 45 and 45 of the piston head 43, and downwardly on. the surfaces 42 of the outer member 25. The respective upward and downward forces developed on the members 26 and 25 causes lifting of the mandrel 14 relative to the setting head 21 sufficiently to set the upper slips -15 against the well casing wall. Of course, the upper slips can be of any conventional design requiring a relatively low initial setting load. After setting, the upper slips 15 grip the casing and prevent upward movement of the upper expander cone 17, and further setting force applied to the mandrel 14 will effect expansion of the packing element 19 and the lower slips 16 against the casing wall, setting being completed when the setting tool parts are telescoped as shown in FIGS. 3A and 3B.

The upward setting force applied to the mandrel 14 is fully developed in the following manner. As previously described, upward strain on the running-in string 13 will generate a fluid pressure in the chamber 47 which is a function of the force applied and the transverse area of the piston ring 52. This pressure acts upwardly on the downwardly facing transverse surfaces 45 and 45' of the piston head 43, and downwardly on the upwardly facing transverse surface 42 of the outer member 25. Inasmuch as the downwardly facing surfaces 45 and 45' provide a cumulative area which is considerably larger than the transverse area of the piston ring 52, the upward force on the inner member 26 is considerably larger than the upward force being applied to the running-in string 13 at the surface. As an illustrative example, the area of the piston ring 52 may be one square inch, while the sum of the areas of the surfaces 45 and 45' may be two square inches. Therefore, an upward pull on the operator member 50 of 20,000 lbs. will develop 20,000 p.s.i. fluid pressure in the chamber 47 which acts on the inner member 26 as an upward force of 40,000 lbs. The area of the surface 42 on the outer member 25 may be, for example, one square inch, so that a downward force of 20,000 lbs. is also developed on the outer member 25. The upper slips 15, however, are gripping the casing wall, so that the net result is an upward setting force of 40,000 lbs. applied to the mandrel 14 to firmly set the packing element 19 and the lower slip 16 against the casing. The lock ring 20 will trap the setting load in the tool in a conventional manner, and when a predetermined force is applied to the shear ring 29, it will fail and release the setting tool 11 from the packer so that the setting tool can be withdrawn from the well, leaving the packer permanently set. During upward movement of the operator member 50 within the inner member 26 during setting, the threads 68 will ratchet through the clutch ring 65 which will lock the operator member in a upper solid position relative to the inner member 26, so that the pipe string can be further manipulated to operate a valve or the like in the packer.

It will now be apparent that a new improved setting tool operable by a pipe string to set well tools in well bores has been disclosed. Due to the greater transverse pressure area of the inner member relative to the piston ring, the upward setting force applied to the packer mandrel is amplified above the strain applied to the running-in string at the earths surface. Thus, the packer can be set at much greater depths than is possible with conventional mechanical setting tools while staying within the allowable tensile strength of the running-in string.

Since certain changes and modifications will occur to those skilled in the art in view of the present disclosure without departing from the concepts of the present invention, it is the aim of the appended claims to cover all such changes and modifications falling within the true spirit and scope of the present invention.

I claim:

1. A setting tool apparatus for use in a well bore, comprising: inner and outer telescopically disposed members, said members being movable in opposite longitudinal directions relative to one another and coupled in force transmitting relationship to relatively movable parts of a well tool; piston means on said members having opposed transverse pressure surfaces and forming a fluid filled chamber; and means disposed within said inner member and movable upwardly relative to said members for generating a fluid pressure in said chamber, whereby the pressure of fluids therein can act upwardly on the pressure surface of said inner member and downwardly on the pressure surface of said outer member to effect telescoping movement of said members in opposite longitudinal directions, said pressure generating means having a transverse pressure surface with lesser area than the pressure area of one of said opposed pressure surfaces.

2. A setting apparatus for use in setting a well tool having normally retracted means movable to expanded positions in response to oppositely directed forces applied thereto, comprising: an inner tubular member adapted for connection to a pipe string; an intermediate tubular member telescopically movable on said inner member; first piston means on said inner member; second piston means on said intermediate member, said second piston means having a larger pressure area than said first piston on said inner member due to upward strain on the running-in string will generate a fluid pressure in said chamber which acts on said second piston means in one longitudinal direction and on said third piston means in the opposite direction to apply oppositely directed forces to parts of the well tool and cause expansive movement of said normally retracted means.

3. The apparatus of claim 2 further including releasable means for preventing longitudinal relative movement between said members during lowering into a well bore, said releasable means being releasable in response to manipulation of the running-in string.

4. The apparatus of claim 2 further including friction drag means on said third member for yieldably resisting movement of said third member in the well bore.

5. A setting apparatus adapted for use at the lower end of a running-in string to set a well tool in a well bore, comprising: inner and outer tubular telescoping members adapted for movement in opposite longitudinal directions, said members being coupled in force transmitting relationship to relatively movable parts of a well tool; first piston means on said outer member sealingly slidable on said inner member and having an upwardly facing transverse pressure surface; second piston means on said inner member sealingly slidable on said outer member and having a downwardly facing transverse pressure surface, a fluid-filled chamber being provided between said pressure surfaces; and means adapted for connection to the lower end of the running-in string and disposed within said inner member and movable upwardly relative to said members by the running-in string for generating a fluid ressure in said chamber, said fluid pressure acting upwardly on said downwardly facing transverse surface and downwardly on said upwardly facing transverse surface to force said members in opposite longitudinal directions, the upward force on said inner member being a multiple of the upward force applied to said generating means by the running-in string.

6. The apparatus of claim 5 further including drag means on said outer member yieldably engageable with a well conduit wall for resisting movement of said outer member along the well conduit wall.

7. The apparatus of claim 6 further including releasable means for preventing relative movement between said generating means and said members, said releasable means being releasable in response to manipulation of the running-in string.

8. The apparatus of claim 6 further including one-way clutch means for permitting upward movement of said generating means relative to said inner member and for preventing downward movement of said generating means relative to said inner member.

References Cited UNITED STATES PATENTS 1,529,409 3/1925 Condra 166224 3,125,162 3/1964 Briggs et al 166-123 3,294,171 12/1966 Kelley 166123 X 3,298,437 l/l967 Conrad 166l23 X 3,360,049 12/1967 Kisling 166-123 DAVID H. BROWN, Primary Examiner U.S. Cl. X.R. 166182 

